GO2-23-012, Application to Revise Technical Specifications to Adopt Tstf-541, Add Exceptions to Surveillance Requirements for Valves and Dampers Locked in the Actuated Position
| ML23086C103 | |
| Person / Time | |
|---|---|
| Site: | Columbia  |
| Issue date: | 03/27/2023 |
| From: | David Brown Energy Northwest |
| To: | Office of Nuclear Reactor Regulation, Document Control Desk |
| References | |
| GO2-23-012, TSTF-541 | |
| Download: ML23086C103 (1) | |
Text
David P. Brown Columbia Generating Station P.O. Box 968, PE23 Richland, WA 99352-0968 509.377.8385 dpbrown@energy-northwest.com GO2-23-012 10 CFR 50.90 U.S. Nuclear Regulatory Commission ATTN: Document Control Desk Washington, DC 20555-0001
Subject:
COLUMBIA GENERATING STATION, DOCKET NO. 50-397 APPLICATION TO REVISE TECHNICAL SPECIFICATIONS TO ADOPT TSTF-541, ADD EXCEPTIONS TO SURVEILLANCE REQUIREMENTS FOR VALVES AND DAMPERS LOCKED IN THE ACTUATED POSITION
Dear Sir or Madam:
Pursuant to 10 CFR 50.90, Energy Northwest is submitting a request for an amendment to the Technical Specifications (TS) for Columbia Generating Station (Columbia).
Energy Northwest requests adoption of TSTF-541 Rev. 2, "Add Exceptions to Surveillance Requirements for Valves and Dampers Locked in the Actuated Position,"
which is an approved change to the Standard Technical Specifications (STS), into the Columbia Technical Specifications (TS). The proposed amendment modifies certain TS Surveillance Requirements (SR) by adding exceptions to consider the SR met when automatic valves or dampers are locked, sealed, or otherwise secured in the actuated position, in order to consider the SR met. Securing the automatic valve or damper in the actuated position may affect the operability of the system or any supported systems.
The associated Limiting Condition for Operation is met if the subject structure, system or component remains operable (i.e., capable of performing its specified safety function).
The enclosure to this letter provides a description and assessment of the proposed changes. Attachment 1 provides the existing TS pages marked up to show the proposed changes. Attachment 2 provides revised (clean) TS pages. Attachment 3 provides existing TS Bases pages marked to show the proposed changes and is provided for information only.
Energy Northwest requests that the amendment be reviewed under the Consolidated Line Item Improvement Process (CLIIP). Approval of the proposed amendment is requested within one year of completion of the NRCs acceptance review. Once approved, the amendment shall be implemented within 120 days.
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March 27, 2023 ENERGY NORTHWEST
GO2-23-012 Page 2 of 2 There are no regulatory commitments made in this submittal.
In accordance with 10 CFR 50.91, Energy Northwest is notifying the State of Washington of this amendment request by transmitting a copy of this application, with attachments to the designated State Official.
If you should have any questions regarding this submittal, please contact Mr. R. M.
Garcia, Licensing Supervisor, at 509-377-8463.
I declare under penalty of perjury that the foregoing is true and correct.
Executed this ______ day of ___________, 2023.
Respectfully, David P Brown Site Vice President
Enclosures:
- 1. Description and Assessment Attachments:
- 1. Proposed Technical Specification Changes (Mark-Up)
- 2. Proposed Technical Specification Changes (Clean Pages)
- 3. Revised Technical Specification Bases Changes (Mark-Up for Information Only) cc: NRC RIV Regional Administrator NRC NRR Project Manager NRC Senior Resident Inspector/988C CD Sonoda - BPA/1399 EFSECutc.wa.gov - EFSEC E Fordham - WDOH R Brice - WDOH L Albin - WDOH
" #
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GO2-23-012 Page 1 of 5 DESCRIPTION AND ASSESSMENT
1.0 DESCRIPTION
Energy Northwest requests adoption of TSTF-541 Rev. 2, "Add Exceptions to Surveillance Requirements for Valves and Dampers Locked in the Actuated Position," which is an approved change to the Standard Technical Specifications (STS), into the Columbia Generating Station (Columbia) Technical Specifications (TS). The proposed amendment modifies the TS Surveillance Requirements (SR) by adding exceptions to consider the SR met when automatic valves or dampers are locked, sealed, or otherwise secured in the actuated position, in order to consider the SR met. Securing the automatic valve or damper in the actuated position may affect the operability of the system or of any supported systems. The associated Limiting Condition for Operation (LCO) is met if the subject structure, system or component (SSC) remains operable (i.e., capable of performing its specified safety function). The following TS are affected by the proposed change.
o TS 3.5.1, ECCS - Operating o TS 3.5.2, Reactor Pressure Vessel (RPV) Water Inventory Control o TS 3.5.3, RCIC System o TS 3.6.4.3, Standby Gas Treatment (SGT) System o TS 3.7.1, Standby Service Water (SW) System and Ultimate Heat Sink (UHS) o TS 3.7.2, High Pressure Core Spray (HPCS) Service Water (SW) System o TS 3.7.3, Control Room Emergency Filtration (CREF) System While the proposed exceptions permit automatic valves and dampers that are locked, sealed, or otherwise secured in the actuated position to be excluded from the SR in order to consider the SR met, the proposed changes will not permit a system that is made inoperable by locking, sealing, or otherwise securing an automatic valve or damper in the actuated position to be considered operable. As stated in the SR 3.0.1 Bases, "Nothing in this Specification, however, is to be construed as implying that systems or components are OPERABLE when: a. The systems or components are known to be inoperable, although still meeting the SRs".
2.0 ASSESSMENT
2.1 Applicability of Safety Evaluation Energy Northwest has reviewed the safety evaluation for TSTF-541 provided to the Technical Specifications Task Force in a letter dated December 10, 2019. This review included a review of the NRC staffs evaluation, as well as the information provided in TSTF-541. As described herein, Energy Northwest has concluded that the justifications presented in TSTF-541 and the safety evaluation prepared by the NRC staff are applicable to Columbia and justify this amendment for the incorporation of the changes to the Columbia TS.
Energy Northwest acknowledges that under the proposed change, the affected valves and dampers may be excluded from the SR when locked, sealed or otherwise secured in the actuated position. However, if the safety analysis assumes movement from the actuated position following an event, or the system is rendered inoperable by locking, sealing, or otherwise
" #
GO2-23-012 Page 2 of 5 securing the valve or damper in the actuated position, then the system cannot perform its specified safety function and is inoperable regardless of whether the SR is met.
Energy Northwest acknowledges for components for which the SR allowance can be utilized, the SR must be verified to have been met within its required Frequency after removing the valve or damper from the locked, sealed or otherwise secured status. If the SR exception is utilized to not test the actuation of a valve or damper and the specified Frequency of the SR is exceeded without testing the component, the SR must be performed on the component when it is returned to service in order to meet the SR.
2.2 Variations Energy Northwest is proposing the following variations from the TS changes described in TSTF-541 or the applicable parts of the NRC staffs safety evaluation:
2.2.1 The Columbia TS utilize different numbering and titles than the STS on which TSTF-541 was based. Specifically, x NUREG-1434 SR 3.6.4.3.4 reads slightly different than the Columbia SR 3.6.4.3.4.
o NUREG-1434 SR 3.6.4.3.4 reads, Verify each SGT filter cooler bypass damper can be opened and the fan started.
o Columbia SR 3.6.4.3.4 reads, Verify each SGT filter cooling recirculation valve can be opened and the fan started.
x NUREG-1434 SR 3.7.1.6 is SR 3.7.1.5 of the Columbia TS. In addition, the Columbia SR 3.7.1.5 has slightly different wording than the NUREG-1434 SR 3.7.1.6.
o NUREG-1434 SR 3.7.1.6 reads, Verify each SSW subsystem actuates on an actual or simulated initiation signal.
o Columbia SR 3.7.1.5 reads, Verify each SW subsystem actuates on an actual or simulated initiation signal.
x NUREG-1434 SR 3.7.2.3 is SR 3.7.2.2 of the Columbia TS. In addition, the Columbia SR 3.7.2.2 has slightly different wording than the NUREG-1434 SR 3.7.2.3.
o NUREG-1434 SR 3.7.2.3 reads, Verify the HPCS SWS actuates on an actual or simulated initiation signal.
o Columbia SR 3.7.2.2 reads, Verify the HPCS SW System actuates on an actual or simulated initiation signal.
" #
GO2-23-012 Page 3 of 5 x NUREG-1434 SR 3.7.3.3 reads slightly different than the Columbia SR 3.7.3.3.
o NUREG-1434 SR 3.7.3.3 reads, Verify each CRFA subsystem actuates on an actual or simulated initiation signal.
o Columbia SR 3.7.3.3 reads, Verify each CREF subsystem actuates on an actual or simulated initiation signal.
These differences are administrative and do not affect the applicability of TSTF-541 to the Columbia TS.
2.2.2 The Columbia TS contain requirements that differ from the STS on which TSTF-541 was based, but these differences do not affect the applicability of the TSTF-541 justification.
x NUREG-1434 TS 3.6.1.7, Residual Heat Removal (RHR) Containment Spray System is TS 3.6.1.5, Residual Heat Removal (RHR) Drywell Spray in the Columbia TS. As such, the SR affected by this change is SR 3.6.1.5.1. However, SR 3.6.1.5.1 of the Columbia TS already contains language to exclude valves that are already locked, sealed, or otherwise secured in position and as a result no changes will be made to SR 3.6.1.5.1 of the Columbia TS.
o Columbia SR 3.6.1.5.1 reads, Verify each RHR drywell spray subsystem manual, power operated, and automatic valve in the flow path that is not locked, sealed, or otherwise secured in position, is in the correct position or can be aligned to the correct position.
x The proposed change to the Columbia SR 3.6.4.3.3 and 3.6.4.3.4 is slightly different than the NUREG-1434 SR 3.6.4.3.3 and 3.6.4.3.4 wording. The Columbia Standby Gas Treatment (SGT) System uses valves instead of dampers so the proposed TS changes has replaced dampers with valves.
2.2.3 The Columbia TS have incorporated TSTF-542 Rev. 2, "Reactor Pressure Vessel Water Inventory Control," which had not been incorporated into the STS on which TSTF-541 was based. The changes in TSTF-541 are equally applicable to new SR 3.5.2.6 and 3.5.2.7 added by TSTF-542. Therefore, the TSTF-541 allowance is added to those SR.
2.2.4 The Columbia TS contain a Surveillance Frequency Control Program. Therefore, the Frequency for the affected SR is "In accordance with the Surveillance Frequency Control Program." This has no effect on the applicability of the proposed change.
2.3 Licensee Verifications Energy Northwest confirms that existing administrative processes, such as the Corrective Action Program, Operability Determination process, the maintenance, design control, configuration control, and operating procedures, etc., will be used to assess the operability of the system or of any supported systems when utilizing the SR allowances, which includes consideration of whether movement of the affected valves or dampers following an event is assumed in the safety analysis.
" #
GO2-23-012 Page 4 of 5
3.0 REGULATORY ANALYSIS
3.1 No Significant Hazards Consideration Determination Energy Northwest requests adoption of TSTF-541 Rev. 2, "Add Exceptions to Surveillance Requirements for Valves and Dampers Locked in the Actuated Position," which is an approved change to the STS, into the Columbia TS. The proposed amendment modifies the TS SR by adding exceptions to consider the SR met when automatic valves or dampers are locked, sealed, or otherwise secured in the actuated position, in order to consider the SR met. Securing the automatic valve or damper in the actuated position may affect the operability of the system or of any supported systems. The associated LCO is met if the subject SSC remains operable (i.e.,
capable of performing its specified safety function).
Energy Northwest has evaluated whether or not a significant hazards consideration is involved with the proposed amendment(s) by focusing on the three standards set forth in 10 CFR 50.92, "Issuance of amendment," as discussed below:
- 1.
Does the proposed amendment involve a significant increase in the probability or consequences of an accident previously evaluated?
Response: No The proposed change revises SRs by adding exceptions excluding from actuation and isolation time testing those valves and dampers that are locked, sealed or otherwise secured in the actuated position. The performance or lack of performance of SRs is not an initiator of any accident previously evaluated. As a result, the proposed change has no effect on the probability of any accident previously evaluated. The proposed change excludes performance of portions of certain SRs, but the SSC must still be capable of performing the safety functions assumed in the accident analysis. Otherwise, the SSC is inoperable, and the associated TS Actions are followed. As a result, the SSCs continue to perform their mitigating functions and the consequences of any accident previously evaluated are not affected.
Therefore, the proposed change does not involve a significant increase in the probability or consequences of an accident previously evaluated.
- 2.
Does the proposed amendment create the possibility of a new or different kind of accident from any accident previously evaluated?
Response: No The proposed change revises SRs by adding exceptions excluding from actuation and isolation time testing those valves and dampers that are locked, sealed or otherwise secured in the actuated position. The proposed change will not change the design function or operability requirements of the affected SSCs. The SSC must still be capable of performing the safety functions assumed in the accident analysis or the SSC is inoperable, and the associated TS Actions are followed. The proposed change does not
" #
GO2-23-012 Page 5 of 5 create any credible new failure mechanisms, malfunctions, or accident initiators not considered in the design and licensing bases.
Therefore, the proposed change does not create the possibility of a new or different kind of accident from any accident previously evaluated.
- 3.
Does the proposed amendment involve a significant reduction in a margin of safety?
Response: No The proposed change revises SRs by adding exceptions excluding from actuation and isolation time testing those valves and dampers that are locked, sealed or otherwise secured in the actuated position. The proposed change does not alter the manner in which safety limits, limiting safety system settings or limiting conditions for operation are determined. The safety analysis assumptions and acceptance criteria are not affected by this change.
Therefore, the proposed change does not involve a significant reduction in a margin of safety.
Based on the above, Energy Northwest concludes that the proposed change presents no significant hazards consideration under the standards set forth in 10 CFR 50.92(c), and, accordingly, a finding of "no significant hazards consideration" is justified.
3.2 Conclusion In conclusion, based on the considerations discussed above, (1) there is reasonable assurance that the health and safety of the public will not be endangered by operation in the proposed manner, (2) such activities will be conducted in compliance with the Commissions regulations, and (3) the issuance of the amendment will not be inimical to the common defense and security or to the health and safety of the public.
- 4.
ENVIRONMENTAL CONSIDERATION The proposed change would change a requirement with respect to installation or use of a facility component located within the restricted area, as defined in 10 CFR 20, or would change an inspection or surveillance requirement. However, the proposed change does not involve (i) a significant hazards consideration, (ii) a significant change in the types or significant increase in the amounts of any effluents that may be released offsite, or (iii) a significant increase in individual or cumulative occupational radiation exposure. Accordingly, the proposed change meets the eligibility criterion for categorical exclusion set forth in 10 CFR 51.22(c)(9).
Therefore, pursuant to 10 CFR 51.22(b), no environmental impact statement or environmental assessment need be prepared in connection with the proposed change.
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GO2-23-012 Page 1 of
Proposed Technical Specification Changes (Mark-Up)
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ECCS - Operating 3.5.1 Columbia Generating Station 3.5.1-5 Amendment No. 169,205,225,236 238 246 249 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.1.5
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Vessel injection/spray may be excluded.
Verify each ECCS injection/spray subsystem actuates on an actual or simulated automatic initiation signalH[FHSWIRUYDOYHVWKDWDUH
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Valve actuation may be excluded.
Verify the ADS actuates on an actual or simulated automatic initiation signal.
In accordance with the Surveillance Frequency Control Program SR 3.5.1.7
NOTE------------------------------
Not required to be performed until 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> after reactor steam pressure and flow are adequate to perform the test.
Verify each required ADS valve opens when manually actuated.
In accordance with the Surveillance Frequency Control Program SR 3.5.1.8
NOTE------------------------------
ECCS actuation instrumentation is excluded.
Verify the ECCS RESPONSE TIME for each ECCS injection/spray subsystem is within limits.
In accordance with the Surveillance Frequency Control Program
" #
RPV Water Inventory Control 3.5.2 Columbia Generating Station 3.5.2-5 Amendment No. 251 264 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.2.4 Verify, for the required ECCS injection/spray subsystem, locations susceptible to gas accumulation are sufficiently filled with water.
In accordance with the Surveillance Frequency Control Program SR 3.5.2.5
NOTE------------------------------
1.
Operation may be through the test return line.
2.
Credit may be taken for normal system operation to satisfy this SR.
Operate the required ECCS injection/spray subsystem for 10 minutes.
In accordance with the Surveillance Frequency Control Program SR 3.5.2.6 Verify each valve credited for automatically isolating a penetration flow path actuates to the isolation position on an actual or simulated isolation signal
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SW System and UHS 3.7.1 Columbia Generating Station 3.7.1-3 Amendment No. 149,169,225,236 238 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.1.3
NOTE------------------------------
Isolation of flow to individual components does not render SW subsystem inoperable.
Verify each SW subsystem manual, power operated, and automatic valve in the flow path servicing safety related systems or components, that is not locked, sealed, or otherwise secured in position, is in the correct position.
In accordance with the Surveillance Frequency Control Program SR 3.7.1.4 Verify average sediment depth in each UHS spray pond is < 0.5 ft.
In accordance with the Surveillance Frequency Control Program SR 3.7.1.5 Verify each SW subsystem actuates on an actual or simulated initiation signalH[FHSWIRUYDOYHVWKDWDUH
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HPCS SW System 3.7.2 Columbia Generating Station 3.7.2-1 Amendment No. 149,169 225 238 3.7 PLANT SYSTEMS 3.7.2 High Pressure Core Spray (HPCS) Service Water (SW) System LCO 3.7.2 The HPCS SW System shall be OPERABLE.
APPLICABILITY:
MODES 1, 2, and 3.
ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. HPCS SW System inoperable.
A.1 Declare HPCS System inoperable.
Immediately SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.2.1
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GO2-23-012 Attachment
Page 1 of
Proposed Technical Specification Changes ($MFBO1BHFT)
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ECCS - Operating 3.5.1 Columbia Generating Station 3.5.1-5 Amendment No. 169,205,225,236 238 246 249 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.1.5
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NOTE------------------------------
Valve actuation may be excluded.
Verify the ADS actuates on an actual or simulated automatic initiation signal.
In accordance with the Surveillance Frequency Control Program SR 3.5.1.7
NOTE------------------------------
Not required to be performed until 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> after reactor steam pressure and flow are adequate to perform the test.
Verify each required ADS valve opens when manually actuated.
In accordance with the Surveillance Frequency Control Program SR 3.5.1.8
NOTE------------------------------
ECCS actuation instrumentation is excluded.
Verify the ECCS RESPONSE TIME for each ECCS injection/spray subsystem is within limits.
In accordance with the Surveillance Frequency Control Program
" #
RPV Water Inventory Control 3.5.2 Columbia Generating Station 3.5.2-5 Amendment No. 251 264 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.2.4 Verify, for the required ECCS injection/spray subsystem, locations susceptible to gas accumulation are sufficiently filled with water.
In accordance with the Surveillance Frequency Control Program SR 3.5.2.5
NOTE------------------------------
1.
Operation may be through the test return line.
2.
Credit may be taken for normal system operation to satisfy this SR.
Operate the required ECCS injection/spray subsystem for 10 minutes.
In accordance with the Surveillance Frequency Control Program SR 3.5.2.6 Verify each valve credited for automatically isolating a penetration flow path actuates to the isolation position on an actual or simulated isolation signal
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SW System and UHS 3.7.1 Columbia Generating Station 3.7.1-3 Amendment No. 149,169,225,236 238 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.1.3
NOTE------------------------------
Isolation of flow to individual components does not render SW subsystem inoperable.
Verify each SW subsystem manual, power operated, and automatic valve in the flow path servicing safety related systems or components, that is not locked, sealed, or otherwise secured in position, is in the correct position.
In accordance with the Surveillance Frequency Control Program SR 3.7.1.4 Verify average sediment depth in each UHS spray pond is < 0.5 ft.
In accordance with the Surveillance Frequency Control Program SR 3.7.1.5 Verify each SW subsystem actuates on an actual or simulated initiation signalH[FHSWIRUYDOYHVWKDWDUH
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HPCS SW System 3.7.2 Columbia Generating Station 3.7.2-1 Amendment No. 149,169 225 238 3.7 PLANT SYSTEMS 3.7.2 High Pressure Core Spray (HPCS) Service Water (SW) System LCO 3.7.2 The HPCS SW System shall be OPERABLE.
APPLICABILITY:
MODES 1, 2, and 3.
ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. HPCS SW System inoperable.
A.1 Declare HPCS System inoperable.
Immediately SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.2.1
NOTE------------------------------
Isolation of flow to individual components does not render HPCS SW System inoperable.
Verify each HPCS SW System manual, power operated, and automatic valve in the flow path, that is not locked, sealed, or otherwise secured in position, is in the correct position.
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RPV Water Inventory Control B 3.5.2 Columbia Generating Station B 3.5.2-8 Revision 121 BASES SURVEILLANCE REQUIREMENTS (continued)
SR 3.5.2.4 The flow path piping has the potential to develop voids and pockets of entrained air. Maintaining the pump discharge lines of the required ECCS injection/spray subsystems full of water ensures that the ECCS subsystem will perform properly. This may also prevent a water hammer following an ECCS actuation. One acceptable method of ensuring that the lines are full is to vent at the high points.
The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.
SR 3.5.2.5 Verifying that the required ECCS injection/spray subsystem can be manually aligned, and the pump started and operated for at least 10 minutes demonstrates that the subsystem is available to mitigate a draining event. This SR is modified by two Notes. Note 1 states that testing the ECCS injection/spray subsystem may be done through the test return line to avoid overfilling the refueling cavity. Note 2 states that credit for meeting the SR may be taken for normal system operation that satisfies the SR such as using the RHR mode of LPCI for 10 minutes.
The minimum operating time of 10 minutes was based on engineering judgement.
The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.
SR 3.5.2.6 Verifying that each valve credited for automatically isolating a penetration flow path actuates to the isolation position on an actual or simulated RPV water level isolation signal is required to prevent RPV water inventory from dropping below the TAF should an unexpected draining event occur.
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RPV Water Inventory Control B 3.5.2 Columbia Generating Station B 3.5.2-9 Revision 121 BASES SURVEILLANCE REQUIREMENTS (continued)
REFERENCES
Information Notice 84-81 "Inadvertent Reduction in Primary Coolant Inventory in Boiling Water Reactors During Shutdown and Startup,"
November 1984.
Information Notice 86-74, "Reduction of Reactor Coolant Inventory Because of Misalignment of RHR Valves," August 1986.
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SR 3.5.2.7 This Surveillance verifies that a required LPCI subsystem, or LPCS System, or HPCS System can be manually aligned and started from the control room, including any necessary valve alignment, instrumentation, or controls, to transfer water from the suppression pool or CST to the RPV. 7KH65H[FOXGHVDXWRPDWLFYDOYHVWKDWDUHORFNHG
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This SR is modified by a Note that excludes vessel injection/spray during the Surveillance. Since all active components are testable and full flow can be demonstrated by recirculation through the test line, coolant injection into the RPV is not required during the Surveillance.
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SW System and UHS B 3.7.1 Columbia Generating Station B 3.7.1-7 Revision 93 BASES SURVEILLANCE REQUIREMENTS (continued)
SR 3.7.1.4 Verification of the average sedimentation depth in each UHS spray pond ensures that adequate long term (30 days) cooling can be maintained.
The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.
SR 3.7.1.5 This SR verifies that the automatic isolation valves of the SW System will automatically switch to the safety or emergency position to provide cooling water exclusively to the safety related equipment during an accident event. This is demonstrated by use of an actual or simulated initiation signal. This SR also verifies the automatic start capability of the SW pump in each subsystem.7KH65H[FOXGHVDXWRPDWLFYDOYHVWKDW
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VHFXUHGSRVLWLRQUHTXLUHVDQDVVHVVPHQWRIWKHRSHUDELOLW\\RIWKHV\\VWHP
RUDQ\\VXSSRUWHGV\\VWHPVLQFOXGLQJZKHWKHULWLVQHFHVVDU\\IRUWKHYDOYH
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The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.
REFERENCES
Regulatory Guide 1.27, Revision 1, March 1974.
FSAR, Sections 9.2.5 and 9.2.7.
FSAR, Table 9.2-5.
FSAR, Section 6.2.2.3.
FSAR, Chapter 15.
FSAR, Table 6.2-2.
" #
HPCS SW System B 3.7.2 Columbia Generating Station B 3.7.2-2 Revision 93 BASES ACTIONS A.1 When the HPCS SW System is inoperable, the capability of the HPCS System to perform its intended function cannot be ensured. Therefore, if the HPCS SW System is inoperable, the HPCS System must be declared inoperable immediately and the applicable Condition(s) of LCO 3.5.1, "ECCS - Operating," entered.
SURVEILLANCE SR 3.7.2.1 REQUIREMENTS Verifying the correct alignment for each manual, power operated, and automatic valve in the HPCS SW System flow path provides assurance that the proper flow paths will exist for HPCS SW System operation. This SR does not apply to valves that are locked, sealed, or otherwise secured in position, since these valves are verified to be in the correct position prior to locking, sealing, or securing.
A valve is also allowed to be in the nonaccident position and yet considered in the correct position, provided it can be automatically realigned to its accident position within the required time. This SR does not require any testing or valve manipulation; rather, it involves verification that those valves capable of potentially being mispositioned are in the correct position. This SR does not apply to valves that cannot be inadvertently misaligned, such as check valves.
This SR is modified by a Note indicating that isolation of the HPCS SW System to components or systems may render those components or systems inoperable, but does not affect the OPERABILITY of the HPCS SW System. As such, when the HPCS SW System pump and all valves and piping are OPERABLE, but a branch connection off the main header is isolated, the HPCS SW System is still OPERABLE.
The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.
SR 3.7.2.2 This SR verifies that the automatic valves of the HPCS SW System will automatically switch to the safety or emergency position to provide cooling water exclusively to the safety related equipment during an accident event. This is demonstrated by use of an actual or simulated initiation signal. This SR also verifies the automatic start capability of the HPCS SW pump. 7KH65H[FOXGHVDXWRPDWLFYDOYHVWKDWDUHORFNHG
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" #
HPCS SW System B 3.7.2 Columbia Generating Station B 3.7.2-2 Revision 93 BASES 4637&*-"/$&3&26*3&.&/54 DPOUJOVFE
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The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.
REFERENCES 1.
FSAR, Section 9.2.7.
2.
FSAR, Chapter 6.
3.
FSAR, Chapter 15.
4.
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